KR102093454B1 - Integrated ebullated-bed process for whole crude oil upgrading - Google Patents

Abstract

A system and method for upgrading the entire crude feed in an integrated boiling-bed and hydrotreating facility is provided, wherein the whole crude oil is flashed into a flashed DC fraction and atmospheric residue fraction. The atmospheric residue fraction is hydrogenated in the boiling-bed reaction zone, while the product fraction produced from the boiling-bed reaction zone and the flashed DC fraction are hydrotreated in a fixed-bed reaction zone. The oil fraction from the hydrotreating facility and the unconverted residue oil fraction from the boiling-bed reaction zone can be combined to produce upgraded synthetic crude oil.

Description

INTEGRATED EBULLATED-BED PROCESS FOR WHOLE CRUDE OIL UPGRADING}

This application claims the priority of U.S. Provisional Patent Application No. 61 / 642,784, filed May 4, 2012, the disclosure of which is incorporated herein by reference.

The present invention relates to a process for upgrading the quality of whole crude oil.

Crude oil has traditionally been subjected to a variety of cracking, solvent treatment and hydroconversion processes to produce the desired slate of fuels, lubricating oil products, chemicals, chemical feedstocks and the like. It is processed by distillation accompanied with a. Examples of conventional refining processes include distillation of crude oil in atmospheric distillation to recover gas oil, naphtha, gaseous products, and atmospheric residuum. Streams recovered from crude oil distillation at the boiling point of fuel have customarily been used directly as fuel. Generally, the atmospheric residue is further fractionated in a reduced pressure distillation unit to produce reduced pressure gas oil and reduced pressure residue oil. The reduced pressure gas oil is generally cracked by a flow catalytic cracking unit or hydrocracking to provide a more valuable light transport fuel product. The reduced pressure residue can be further processed to convert it into a more valuable product. For example, the reduced pressure resid upgrade process may include one or more resid hydrotreating, resid flow catalytic cracking, coking, and solvent deasphhalting.

There are three general reactor types used in the refining industry: fixed-bed, ebullated-bed, and mobile-bed. The decision to use a particular type of reactor is based on a number of criteria including feedstock, desired conversion percentage, flexibility, lifetime and product quality, and the like. In purification, the stop-time for replacement or regeneration of the catalyst should be as short as possible. Moreover, the economy of the process is to handle feed streams containing varying amounts of pollutants such as sulfur, nitrogen, metals and / or organometallic compounds, such as those found in reduced pressure gas oils, deasphalted oils, and residue oils. Will depend on the versatility of the system.

In a fixed-bed reactor, the catalyst particles are stationary and do not move relative to a fixed reference frame. Fixed-bed technology has significant problems in treating certain heavy fillers containing relatively high amounts of heteroatoms, metals and asphaltenes, as these contaminants cause rapid inertness of the catalyst and plugging of the reactor. Because. In conventional fixed-bed reactors, the hydroprocessing catalyst is regularly replaced to maintain the desired level of catalyst activity and throughput. Multiple fixed-bed reactors connected in series can be used to achieve a relatively high conversion of heavy feedstock boiling above the cut point in the range of 300-400 ° C, but this design allows for high equipment investments and, For raw materials, commercially impractical, eg, catalyst replacement is required every 3-4 months.

The boiling-bed reactor has been developed to overcome plugging problems commonly associated with fixed-bed reactors, for example, for reduced pressure residues, as conversion conditions increase, and during relatively heavy feedstock processing. In general, a boiling-bed reactor comprises a stream of liquid or a slurry of liquid, solid and gas, flowing simultaneously through a vertically-oriented cylindrical vessel containing a catalyst. The catalyst is placed movably in the liquid and, in the case of a stationary phase, has a gross volume dispersed through a liquid medium larger than the volume of the mass. In a boiling-bed reactor, the catalyst is in an expanded bed, thereby countering the plugging problem associated with fixed-bed reactors. The flow properties of the catalyst in the boiling-bed reactor also allow for on-line catalyst replacement of small portions of the bed. This results in high net bed activity that does not change over time. Initial boiling-layer processes and systems were described by Johanson in U.S. Patent Nos. 2,987,465 and 3,197,288, all of which are incorporated herein by reference.

Mobile-bed reactors combine the specific advantages of fixed-bed operation with the relatively easy catalyst replacement of boiling-bed technology. Operating conditions are generally more severe than those commonly used in fixed-bed reactors, ie, the pressure can exceed 200 kg / cm 2 and the temperature can be in the range of 400 ° C-430 ° C. During catalyst replacement, catalyst movement is slow compared to the linear velocity of the feed. The catalyst addition and recovery is carried out, for example, through a slurry system at the top and bottom of the reactor. The advantage of the mobile-bed reactor is that the upper layer of the mobile-bed consists of a new catalyst, the source of contamination deposited on top of the layer moves downward with the catalyst, and is released during catalyst recovery in the bottom. Thus, resistance to metals and other pollutants is much greater than for fixed-bed reactors. With this capability, the mobile-bed reactor has advantages over the hydroprocessing of heavy feeds, especially when several reactors are combined in series.

Companies that develop boiling-layer technologies include: Chevron Lummus Global, Axens, Headwaters, Institut Francais du Petrole (IFP) Energies Nouvelles, Hydrocarbon Research Institute (HRI), City Services, Texaco, Hydrocarbon Technologies Inc. (HTI). Commercial names for the boiling-layer technology include: H-Oil, T-Star, and LC-Fining.

One major technical challenge arises when the hydrotreating of the heavy oil fraction or the whole crude oil is the impact of small concentrations of pollutants, such as pollutants, for example organic nickel and vanadium compounds and multi-nuclear aromatic compounds. These organometallic compounds and others have been demonstrated to reduce the activity or useful life of the hydrotreating catalyst. The presence of these metal contaminants and multi-nuclear aromatics results in reduced process performance, increased plant costs and / or increased operating costs of the purification process unit. In the residual fraction of crude oil, metal is deposited on the hydroprocessing catalyst, resulting in catalyst deactivation. The multi-nucleated aromatic compound is a coke precursor and forms coke at high temperatures and also causes catalytic inertness.

Conventional methods are limited in their efficiency for the process of the whole crude oil feed. For example, fixed-bed reactors require shutdown for catalyst unloading and replacement. This reduces the on stream factor and consequently increases the processing cost of the hydroprocessing unit.

Accordingly, it would be desirable to provide an improved system and process for effective treatment of whole crude oil to upgrade the quality of the whole crude oil.

Integrated systems and processes for upgrading the entire crude feedstock are provided to reduce the content of unwanted heteroatom compounds containing metals, sulfur and nitrogen. The process comprises heating the crude oil feedstock; Flashing the heated feedstock to produce a flashed straight run distillate fraction and an atmospheric residual fraction; Hydroprocessing the atmospheric residue fraction in a boiling-bed reaction zone in the presence of a first catalyst system, eg, a boiling-bed reactor catalyst, to produce a boiling-bed reactor effluent; Separating the boiling-bed reactor effluent into a hydrogenated product that also contains hydrogen, a recycled oil fraction and an unconverted residue fraction; Producing a hydrotreated effluent by hydrotreating a stream consisting of the flashed DC fraction and hydroprocessed product in the presence of a second catalyst system, for example a hydrotreating catalyst, in a hydrotreating zone; Separating the hydrogenated effluent to produce a light gas fraction and a hydrogenated oil fraction; Purifying the light gas fraction and recycling the purified light gas fraction to the boiling-bed reactor as a source of hydrogen gas for hydroprocessing; And, optionally, recycling a recycle oil stream to the boiling-bed reaction zone.

In the process herein, the products can be recovered individually or as a mixture. For example, in some embodiments, all or part of the hydrotreated fraction of oil and all or part of unconverted residue fraction can be combined to produce a synthetic crude oil product. In some embodiments, all or part of the hydrotreated fraction of oil can be recovered separately, and all or part of the unconverted residue fraction can be recovered separately.

Other aspects, implementations, and advantages of the process of the present invention are discussed in detail below. Moreover, all of the foregoing background and the following detailed description are merely illustrative of various aspects and implementations, and are intended to provide an overview or framework for understanding the nature and features of claimed features and implementations. Should be. The accompanying drawings are included to provide illustrative and further understanding of various aspects and implementation examples. Together with the rest of the specification, the drawings are provided to illustrate the principles and operation of the described and claimed aspects and implementations.

In addition to the following detailed description, the contents of the foregoing invention will be best understood when referring to the accompanying drawings.
1 is a schematic diagram of an integrated process of a boiling-bed reactor and a fixed-bed reactor for the treatment of whole crude oil.

The process here uses a combination of a boiling-bed reaction zone and a fixed-bed reaction zone to desulfurize and hydrotreat (ie hydrotreat and hydrocrase) the entire crude feedstock to form a low sulfur, low aromatic fuel. The whole crude oil is heated and separated into a flashed DC fraction and an atmospheric residue fraction. The atmospheric residue fraction is hydrogenated in the boiling-bed reactor, while the hydrogenated product and flashed DC fraction are combined and hydrotreated in an in-line fixed-bed reactor. In some embodiments, the fixed-bed reactor only receives hydrogen from the boiling-bed reactor effluent.

The crude oil feed can be desalted, and volatiles are removed prior to desulfurization. A significant portion of the crude oil feed is subjected to desulfurization in the desulfurization reaction zone. Many reactions are expected to occur during the desulfurization process. The metal-containing component of the crude oil feed is demetallized at least partially during the desulfurization process, and nitrogen and oxygen are removed together with sulfur during the desulfurization process.

The yield of the desired fuel product is increased in this process if the desulfurized crude oil product is fractionated, preferably in a multi-stage fractionation zone with atmospheric and reduced pressure distillation columns. Products from the multi-stage distillation include a naphtha fraction, a light gas oil fraction, a reduced pressure gas oil fraction and a residue oil fraction. The naphtha fraction boiling in the 36 ° C.-180 ° C. range can be upgraded in the reforming process to produce gasoline blending components. The light gas oil fraction, which generally has a boiling point below about 370 ° C., can be used directly as a fuel, or can be further hydrogenated for improved fuel properties. In this process, the reduced pressure gas oil fraction is hydrocracked to increase fuel yield and further improve fuel properties. Single or multi-stage hydrocracking reactors can be used. The hydrocracking product comprises at least one low sulfur fuel product that can be recovered during the distillation of the hydrocracking product.

Thus, the process comprises hydrodesulfurizing the crude oil feed in a crude oil desulfurization unit, separating the desulfurized crude oil and separating a naphtha fraction, light gas oil fraction, reduced pressure gas oil fraction and resid fraction, at least one low. Hydrocracking the reduced pressure gas oil to form a sulfur fuel product; And hydrotreating the light gas oil fraction. In some embodiments, this entire integrated process can be performed without the need for tank storage of intermediate products, such as desulfurized crude oil, light gas oil fraction, and reduced pressure gas oil fraction. Since there is no required tank storage of the intermediate product, these processes can be performed without conventional cooling of the intermediate product, thus reducing the operating cost of the process. Another attribute of the process contributes to a reduction in the equipment and operating costs associated with the hydroconversion step, including crude desulfurization, where hydrocracking and hydrotreating is performed using a single hydrogen feed loop.

Thus, integrated refining systems and processes are described to process the entire crude oil, or a significant portion of the crude oil, from the high yield and high selectivity of the desired product to the full range of products. The integrated process utilizes a series of reaction zones, each containing a catalyst of varying composition and properties, to continuously convert progressively lighter and cleaner fuel products.

The integrated process further provides a method for separating, purifying and providing hydrogen into various conversion reaction zones through the use of a single hydrogen separation and pressurization unit.

The integrated process allows a combination of units for reaction in the production of fuel from crude oil feed, product separation, hydrogen separation and recycling, and more effective use of energy usage. In the implementation of the process, a wide range of fuel oil products can be effectively produced with a relatively small number of reaction vessels and product recovery vessels, and a minimal number of support vessels for handling hydrogen and intermediate products. As another advantage, the process can be performed using a smaller number of actuators compared to conventional processes.

The process employs a combination of crude desulfurization tailored to a wide boiling range feed, followed by distillation to form a slightly oily stream, and an integrated hydrocracking / hydroprocessing process to form a wide range of useful fuel and lubricant based raw material products. Based on upgraded bulk. The process provides an effective, less costly alternative to conventional refinery runs that separate crude feeds into multiple fractions of oil and residue, each of which is individually processed in similar but separate upgrade processes. .

Referring to the embodiment schematically illustrated in FIG. 1, the entire crude feed stream 1 is heated in a furnace 19, the heated stream 2 being flashed direct current fraction 3 and atmospheric residue. The fraction (4) is sent to a flash vessel (30) to produce. The atmospheric residue fraction (4), in the presence of a boiling-bed reactor catalyst hydroprocessed to produce a boiling-bed reactor effluent (8) (recirculating hydrogen 22 as described herein and optionally make) With hydrogen (which may be make-up hydrogen 6), for example, through an ebullating pump (21), it is transferred to the boiling-bed reaction zone (10). The boiling-bed reaction zone 10 may contain a single boiling-bed reactor or multiple boiling-bed reactors operated in series. Additionally, although a boiling pump 21 is shown in association with the filler 4 into the boiling-bed reaction zone 10, it is understood that a suitable boiling pump can be associated with the recycle stream. Additionally, the boiling-bed reaction zone 10 may include a boiling bed reactor in which the liquid is internally re-purified with a recycle downcomer or recycled in a structure of external recycling.

The boiling-bed reactor effluent 8 is typically cooled, for example through a heat exchanger 23, and the cooled boiling-bed reactor effluent 9 is in the range of hydrogen gas and naphtha and gas oil. It is separated from the separation unit 20 into a hydroprocessed product stream 11 containing boiling material, an unconverted resid stream 12 and an optional recycle oil stream 18.

The hydroprocessed product stream (11) and the flashed DC fraction (3) are combined and hydrotreated in the presence of a hydrotreating catalyst to hydrotreat the hydrotreated effluent (14) in a fixed-bed hydroprocessing reaction zone (40). To produce. The fixed-bed hydroprocessing reaction zone 40 can contain a single fixed-bed reactor or multiple fixed-bed reactors operated in series. The hydrotreated effluent stream 14 is separated into a light gas stream 15 and a hydrotreated oil stream 16 in a separation zone 50. The light gas stream 15 is purified, for example, in zone 60, and recycle hydrogen 22 is sent to the boiling-bed reactor.

Recirculating oil stream 18 is, for example, by combining the atmospheric residue fraction and the recirculating oil stream 18 from flash vessel 30 to form a combined stream 5 conveyed through boiling pump 21. , Optionally recycled to the boiling-bed reactor 10 for further processing.

In some embodiments, all or part of the hydrotreated oil stream 16 and all or part of the unconverted residue oil stream 12 can be combined to produce a synthetic crude oil product. In some embodiments, all or a portion of the hydrotreated oil stream 16 can be recovered separately, and all or a portion of the unconverted residue oil stream 12 can be recovered separately.

The current process utilizes certain features of the boiling-bed reactor to improve the hydrogenation of the crude oil. The crude oil is flashed in two fractions, and each fraction is desulfurized separately: atmospheric residue in a boiling-bed reactor and oil in a fixed-bed reactor. One advantage derived from integrated systems and processes using two different reactor types is the overall reduction in reactor volume. It provides flexibility and latitude for a refiner to reduce the size of the reactor or operate at the same throughput.

Moreover, in the arrangement of this process, make-up hydrogen is only used in the boiling-bed reactor. The product stream 11 hydrogenated from the boiling-bed reactor comprises off-gas containing hydrogen, which provides reactant hydrogen to the fixed-bed reaction zone 40.

This process uses an in-line hydrogen partial pressure to upgrade the oil in the fixed-bed reaction zone 40 and a boiling-bed reaction zone 10 to upgrade the whole crude oil. Separation of oil from whole crude oil minimizes the degradation of oil and results in higher oil yield in downstream purification operations. Contaminants such as metals and asphaltenes are removed and / or converted in a boiling-bed reactor where the catalyst is added and / or recovered on-line, for example, daily or at certain throughput intervals. .

The integration of dual reactors for upgrading the whole crude oil is more acceptable for the production of upgraded synthetic crude oil. Due to the heavy and messy nature of the feedstock, i.e., asphaltenes and metals content, the boiling-bed reactor is used to process hydrocarbons boiling above the cut point in the range 300-400 ° C, e.g. above 370 ° C, Oils that boil below the cut point in the range 300-400 ° C, for example below 370 ° C, are treated in a fixed-bed reactor with a source of hydrogen derived from the boiling-bed reactor off-gas stream. The boiling-bed reactor is a catalytic replacement system, so metal is removed from the whole crude oil in the boiling bed-reactor. Additionally, the residue oil is decomposed and the decomposed product is also hydrotreated in the fixed-bed reactor. In the example described herein, due to the residue oil conversion, the API specific gravity of Arab light whole crude oil is increased from 33.2 ° to 41.5 °. Additionally, the sulfur content of the Arab Light Total Crude Oil is reduced from 1.973 W% to 0.3 W%, a decrease of about 85%.

Operating conditions for the boiling-bed reactor include a total pressure between about 100 bars and about 200 bars; An operating temperature between about 350 ° C and about 500 ° C; Fluid space velocity between about 0.1 h ^-1 and about 2.0 h ^-1 ; A hydrogen-feed ratio between about 700 standard liters per liter of feed and 2,500 standard liters per liter of feed; And a catalyst replacement rate between a feed of about 0.1 kg / m 3 and a feed of about 5 kg / m 3.

The catalyst used in the boiling-bed reactor may be a catalyst capable of promoting the desired removal and / or conversion of contaminants in the relatively heavy portion of the feed. Suitable boiling-bed reactor catalysts generally contain 2-25 wt% total active metal, in some embodiments 5-20 wt% active metal; Has a total pore volume of 0.30-1.50 cc / gm; Having a total surface area of 100-400 m 2 / g; And / or have an average pore diameter of at least 50 angstrom. Suitable active metals include those selected from the group consisting of elemental groups VIB, VIIB or VIIIB of the periodic table. For example, suitable metals include one or more of cobalt, nickel, tungsten and molybdenum. The support material can be selected from the group consisting of alumina, silica alumina, silica and zeolite.

Operating conditions for the fixed-bed reactor include a total pressure between about 100 bars and about 200 bars; An operating temperature between about 350 ° C and about 500 ° C; Fluid space velocity between about 0.1 h ^-1 and about 2.0 h ^-1 ; And a hydrogen-feed ratio between about 700 standard liters per liter of feed and 2,500 standard liters per liter of feed.

The catalyst used in the fixed-bed reactor may be a catalyst capable of promoting the desired hydrogenation of the relatively light portion of the feed. Suitable fixed-bed reactor catalysts generally contain 2-25 wt% of total active metal, in some embodiments, 5-20 wt% of active metal; Has a total pore volume of 0.30-1.50 cc / gm; Having a total surface area of 100-400 m 2 / g; And / or have an average pore diameter of at least 50 angstrom. Suitable active metals include those selected from the group consisting of elemental groups VIB, VIIB or VIIIB of the periodic table. For example, suitable metals include one or more of cobalt, nickel, tungsten and molybdenum. The support material can be selected from the group consisting of alumina, silica alumina, silica and zeolite.

Example

A sample of 1000 Kg of Arab light crude oil is heated and flashed in an atmospheric pressure flash unit, resulting in a direct current fraction and an atmospheric residue fraction. The properties of the whole crude oil and its fractions are provided in Table 1.

Characteristics of Arab light crude oil and its fractions Fraction Whole crude oil Oil Atmospheric residue Yield weight% 100.0 57.3 42.7 Yield volume% 100.0 62.3 37.7 Specific gravity, ° API 33.2 49.4 15.0 Specific Gravity, 60/60 ℉ 0.859 0.782 0.966 Sulfur, W% 1.9732 0.75 3.21

The atmospheric residue fraction is mixed with hydrogen and sent to a boiling bed reactor operating at 440 ° C., a hydrogen partial pressure of 160 bars, a fluid space velocity of 0.2 h ⁻¹ , and a catalyst replacement rate of 0.86 Kg catalyst / m 3 of oil. The boiling-bed reactor has an external recirculation vessel, from which unconverted oil is recycled back to the reactor at a recycle to feed ratio of 6.

The DC fraction from the flash vessel, the hydrotreated fraction containing hydrogen and the light gas from the boiling-bed unit are combined and sent to the fraction hydrotreating unit containing Ni-Mo on the alumina catalyst. No additional hydrogen is injected since the hydrogen partial pressure from the boiling-bed unit is sufficient for the hydrotreating reactor. The hydrotreater is operated at a fluid space velocity of 1 h ^-1 at 380 ° C. The hydrotreated oil and unconverted atmospheric residue are combined to produce a synthetic crude oil having an API specific gravity of 41.5 ° and a sulfur content of 0.31 W%. The improvement in total API specific gravity is 8 degrees, while 85 W% of sulfur is removed from crude oil. This results in a significant premium for the crude oil produced. The process material balance (Material Balance) is provided in Table 2.

Material balance Stream people Stream # Flow, Kg / h Density, Kg / L API specific gravity, ° Sulfur, ppmw Whole crude oil One 1,000 0.859 33.1 19,732 Whole crude oil heated 2 1,000 0.859 33.1 19,732 Oil 3 623 0.782 49.4 10 Atmospheric Residue (AR) 4 377 0.966 15.0 32,100 AR + external recirculation 5 2,639 1.031 5.7 12,000 Make-up hydrogen 6 15 - - - Reactor inlet 7 2,655 1.031 5.7 12,000 Reactor outlet 8 2,655 0.966 15 6500 Cooled reactor effluent 9 2,655 0.966 15 6500 External recirculation 18 2,262 0.966 15.0 6500 Hydrocracking products 11 147 0.815 42.1 1,259 Unconverted residue 12 245 0.966 15.0 12,000 Hydrogenation facility inlet 13 770 0.788 48.0 643 Hydrogen treatment facility outlet 14 770 10 Light gas 15 39 Hydrogenated oil 16 732 0.768 52.6 10 Synthetic crude oil 17 977 0.818 41.5 3,018

Although the methods and systems of the present invention have been described above and in the accompanying drawings, modifications will be apparent to those skilled in the art, and the scope of protection of the present invention will be limited by the following claims.

Claims (10)

a. Heating the crude oil feed and flashing the heated crude oil feed to produce a flashed DC fraction and atmospheric residue fraction;
b. Hydrogenating the fraction of the atmospheric residue in a boiling-bed reaction zone in the presence of hydrogen and a boiling-bed reactor catalyst to produce a boiling-bed reactor effluent, wherein the boiling-bed reaction zone is operated continuously with multiple boiling- Containing a bed reactor or a single boiling-bed reactor, operating conditions for the boiling-bed reactor include a catalyst replacement rate between a feed of 0.1 kg / m 3 and a feed of 5 kg / m 3, wherein the boiling-bed reactor catalyst is Having a total pore volume of 0.30-1.50 cc / gm, a total surface area of 100-400 m2 / g, and an average pore diameter of at least 50 Angstroms, the boiling-bed reactor catalyst consists of a group of elements VIB, VIIB or VIIIB of the periodic table At least one active metal selected from the group and a support material selected from the group consisting of alumina, silica alumina, silica and zeolite;
c. Separating the boiling-bed reactor effluent into a hydrogenated product stream containing hydrogen, a recycle oil stream and an unconverted residue stream;
d. Hydrogenating the combined stream of the flashed DC fraction and hydrogenated product stream containing hydrogen in the presence of a hydrotreating catalyst in a hydrotreating facility to produce a hydrotreated effluent by hydrotreating in a fixed-bed hydroprocessing zone. Wherein a portion of the hydrogen from the hydroprocessed product stream forms at least a portion of the hydrogen needed for the hydroprocessing reaction;
e. Separating the hydrotreated effluent to produce a light gas stream and a hydrotreated oil stream;
f. Combining the hydrogenated oil stream and the unconverted residue oil stream to produce a synthetic crude oil product;
g. Undesired heteroatom compounds containing metal, sulfur and nitrogen, comprising purifying the light gas stream and recycling the purified light gas stream to the boiling-bed reactor as a source of hydrogen gas for hydroprocessing. How to upgrade the crude oil feed by reducing its content. delete The method according to claim 1,
The method further comprises recycling the recycle oil stream to the boiling-bed reaction zone. The method according to claim 1,
The hydrogen contained in the hydroprocessed product stream upgrades the crude oil feed, the sole source of hydrogen for hydroprocessing in the fixed-bed hydroprocessing zone. The method according to claim 1,
The flashed DC oil is a method of upgrading a crude oil feed containing naphtha and gas oil fractions boiling below a cut point in the range of 300 ° C to 400 ° C. delete The method according to claim 1,
Operating conditions for the boiling-bed reactor (s) are:
Total pressure between 100 bars and 200 bars;
Operating temperature between 350 ° C and 500 ° C;
Fluid space velocity between 0.1 h ^-1 and 2.0 h ^-1 ; And
A method of upgrading a crude oil feed comprising a hydrogen-feed ratio between 700 standard liters per liter of feed and 2,500 standard liters per liter of feed. The method according to claim 1,
The fixed-bed hydroprocessing zone is a method of upgrading a crude oil feed containing multiple fixed-bed reactors or a single fixed-bed reactor operated continuously. The method according to claim 8,
Operating conditions for the fixed-bed reactor (s) are:
Total pressure between 100 bars and 200 bars;
Operating temperature between 350 ° C and 450 ° C;
Fluid space velocity between 0.1 h ^-1 and 2.0 h ^-1 ; And
A method of upgrading a crude oil feed comprising a hydrogen-feed ratio between 700 standard liters per liter of feed and 2,500 standard liters per liter of feed. The method according to claim 1,
A method of upgrading the crude oil feed in which the make-up hydrogen is introduced into the boiling-bed reaction zone in step (b).

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